CN107818185B - Method for acquiring tight sandstone formation factor - Google Patents
Method for acquiring tight sandstone formation factor Download PDFInfo
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- CN107818185B CN107818185B CN201610817598.2A CN201610817598A CN107818185B CN 107818185 B CN107818185 B CN 107818185B CN 201610817598 A CN201610817598 A CN 201610817598A CN 107818185 B CN107818185 B CN 107818185B
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- G—PHYSICS
- G06—COMPUTING; CALCULATING OR COUNTING
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- G06F30/00—Computer-aided design [CAD]
- G06F30/20—Design optimisation, verification or simulation
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- E—FIXED CONSTRUCTIONS
- E21—EARTH DRILLING; MINING
- E21B—EARTH DRILLING, e.g. DEEP DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B49/00—Testing the nature of borehole walls; Formation testing; Methods or apparatus for obtaining samples of soil or well fluids, specially adapted to earth drilling or wells
Abstract
The invention discloses a method for acquiring tight sandstone formation factors, which comprises the following steps: determining mathematical models among the calculated values of the Archie's formula, the measured data and the irreducible water saturation of the rock sample with the porosity less than the porosity threshold value based on the experimental data; and correcting the calculation value of the Archie formula of the measurement target with the porosity smaller than the porosity threshold value based on the mathematical model according to the logging information to obtain the formation factor of the measurement target. The invention aims at the problem of stratum factor acquisition in tight sandstone well logging interpretation, and establishes a new method and a new flow for acquiring stratum factors based on irreducible water saturation. Compared with the prior art, the method is simple and practical to operate, and has a good application effect in practical well logging interpretation.
Description
Technical Field
The invention relates to the field of geological development, in particular to a method for acquiring tight sandstone formation factors.
Background
Determining formation factors is an important part in the evaluation of the oil logging interpretation saturation. Formation factor determination has long been made using a result published by american well logging engineers g.e. archie in 1942 (known as the aldrich formula) and found by analysis of a large number of petroelectric experimental data: in log-log scale, "clean" sandstone formation factors are linear with porosity and are expressed as follows:
wherein: f is a stratum factor and is dimensionless; r0Resistivity at 100% water in the rock sample, ohm-meter; rwPore water resistivity, ohm.m; phi is the porosity of the rock, decimal; a. m is a constant related to the rock properties (lithology constants, in general, a ≈ 1, m ≈ 2).
Research results of g.e. archie are mainly based on measurements of porosity and resistivity of core samples taken from the gulf area of the united states, with the range of porosity of the core samples being 10% to 40%. However, in recent years, with the increase of experimental research on petrophysical experiments on tight sandstone, a great deal of experimental data shows that: under the double logarithmic coordinate, the interrelation between the formation factor and the porosity of the tight sandstone can not be perfectly in line with the Archie's formula. Whether the Archie's formula is suitable for tight sandstone reservoir well logging interpretation is therefore controversial.
Therefore, in order to obtain more accurate formation factors, a new formation factor obtaining method for tight sandstone is needed.
Disclosure of Invention
The invention provides a method for acquiring tight sandstone formation factors, which comprises the following steps:
determining mathematical models among the calculated values of the Archie's formula, the measured data and the irreducible water saturation of the rock sample with the porosity less than the porosity threshold value based on the experimental data;
and correcting the calculation value of the Archie formula of the measurement target with the porosity smaller than the porosity threshold value based on the mathematical model according to the logging information to obtain the formation factor of the measurement target.
In one embodiment, the method comprises:
calculating and obtaining a first stratum factor value of a rock sample with porosity smaller than a porosity threshold value by utilizing an Archie formula;
obtaining a second stratum factor value of the rock sample with the porosity smaller than the porosity threshold value through experimental measurement;
and determining the numerical correspondence between the ratio of the second formation factor value to the first formation factor value and the irreducible water saturation according to experimental data of the rock sample with the porosity smaller than the porosity threshold value, and establishing the mathematical model according to the numerical correspondence.
In one embodiment, the method comprises:
calculating and obtaining a third stratum factor value of the measurement target by utilizing an Archie formula based on the logging information;
acquiring the irreducible water saturation of the measurement target based on the logging information;
and correcting the third formation factor value according to the irreducible water saturation of the measurement target and the mathematical model to obtain the formation factor value of the measurement target.
In one embodiment, the first formation factor value of the rock sample with the porosity smaller than the porosity threshold value is calculated by using an Archie formula, wherein:
determining the value of the lithological constant of the Archie's formula through a plurality of rock sample experimental data with the porosity larger than the porosity threshold;
and calculating formation factors by adopting the Archie formula for rock samples with the porosity smaller than the porosity threshold value based on the value of the lithology constant.
In one embodiment, the values of the lithology constants of the Archie's equation are determined by experimental data on a plurality of rock samples having a porosity greater than a porosity threshold, wherein the values of the lithology constants are obtained from formation factor values and a rock porosity fit.
In one embodiment, the formation factor values are obtained from a petroelectric experiment and the rock porosity is obtained from a physical analysis experiment.
In an embodiment, the numerical correspondence between the ratio of the second formation factor value to the first formation factor value and the irreducible water saturation is determined from experimental data of a rock sample having a porosity less than a porosity threshold, wherein the numerical correspondence is obtained by fitting the second formation factor value, the first formation factor value and the irreducible water saturation of a plurality of rock samples.
In one embodiment, the numerical value correspondence is expressed as:
c＝d×Swi+f
wherein c is the ratio of the second formation factor value to the first formation factor value, SwiD and f are relational coefficients for irreducible water saturation.
In one embodiment, the irreducible water saturation is obtained from a rock sample mercury intrusion experiment, a nuclear magnetic resonance experiment, or a phase permeation experiment.
In one embodiment, the porosity threshold is 10%.
The invention aims at the problem of stratum factor acquisition in tight sandstone well logging interpretation, and establishes a new method and a new flow for acquiring stratum factors based on irreducible water saturation. Compared with the prior art, the method is simple and practical to operate, and has a good application effect in practical well logging interpretation.
Additional features and advantages of the invention will be set forth in the description which follows. Also, some of the features and advantages of the invention will be apparent from the description, or may be learned by practice of the invention. The objectives and some of the advantages of the invention may be realized and attained by the process particularly pointed out in the written description and claims hereof as well as the appended drawings.
Drawings
The accompanying drawings, which are included to provide a further understanding of the invention and are incorporated in and constitute a part of this specification, illustrate embodiments of the invention and together with the description serve to explain the principles of the invention and not to limit the invention. In the drawings:
FIG. 1 is a cross-plot of porosity formation factors experimentally obtained in the prior art;
FIG. 2 is a flow diagram of a method according to an embodiment of the invention;
FIG. 3 is a mathematical model coordinate diagram according to an embodiment of the present invention;
FIG. 4 is a graph comparing calculated results with measured data according to an embodiment of the present invention.
Detailed Description
The following detailed description will be provided for the embodiments of the present invention with reference to the accompanying drawings and examples, so that the practitioner of the present invention can fully understand how to apply the technical means to solve the technical problems, achieve the technical effects, and implement the present invention according to the implementation procedures. It should be noted that, as long as there is no conflict, the embodiments and the features of the embodiments of the present invention may be combined with each other, and the technical solutions formed are within the scope of the present invention.
In the prior art, the formation factors are typically determined using the Archie's formula. However, in recent years, with the increase of experimental research on petrophysical experiments on tight sandstone, a great deal of experimental data shows that: under the double logarithmic coordinate, the interrelation between the formation factor and the porosity of the tight sandstone can not be perfectly in line with the Archie's formula. Whether the Archie's formula is suitable for tight sandstone reservoir well logging interpretation is therefore controversial.
Aiming at the situation, the invention provides a novel method for acquiring the tight sandstone formation factor.
Under the double logarithmic coordinate, the porosity is approximately 10 percent as a boundary, and when the porosity is more than 10 percent, the relationship between sandstone formation factors and the porosity accords with an Archie formula; whereas when the porosity is less than 10%, the sandstone formation factor is significantly deviated toward a decreasing direction, as shown in the porosity formation factor cross-plot of fig. 1 (the abscissa is porosity and the ordinate is formation factor).
For this deviation phenomenon, one reasonable explanation is: when the porosity is less than 10%, the pore diameter of the rock is small, the micro-capillaries are developed quite, a large number of micro-capillaries are connected with one another to form a good conductive path, and the conductive capacity of the micro-capillaries is stronger than that of the pore fluid in the rock described by the Archie's formula, so that the deviation of the relationship between the formation factor and the porosity is caused. From the perspective, the deviation degree of the formation factors measured by experiments and calculated by the Archie's formula is related to the development degree of the microcapillaries, the pore size of the microcapillaries is small, and the microcapillaries are difficult to flow under the formation condition, so that the development condition of the microcapillaries can be reflected by the saturation of the bound water. Through the analysis of the rock physics experimental data, the following results are found: when the porosity is less than 10%, the deviation degree of the formation factors measured by experiments and the calculated formation factors of the Archie formula has a better linear correlation with the rock irreducible water saturation, so that a relational expression of the deviation degree and the irreducible water saturation can be established based on experimental data, and the irreducible water saturation obtained by well logging interpretation can be corrected by combining the relational expression with the formation factors calculated by the Archie formula to obtain more accurate formation factors.
Next, an implementation of the method of the embodiment of the present invention will be described in detail with reference to the drawings. The steps shown in the flow chart of the figure may be performed in a computer system containing, for example, a set of computer executable instructions. Although a logical order of steps is illustrated in the flowcharts, in some cases, the steps illustrated or described may be performed in an order different than presented herein.
In one embodiment of the invention, a mathematical model between calculated values of the Archie's formula, measured data, and irreducible water saturation of a rock sample having a porosity less than a porosity threshold is first determined based on experimental data. Specifically, as shown in fig. 2, a first formation factor value (calculated value of the alzhen formula) of the rock sample with the porosity smaller than the porosity threshold is calculated and obtained by using the alzhen formula (step S211); experimentally measuring to obtain a second formation factor value (experimentally measured value) of the rock sample having a porosity smaller than the porosity threshold (step S212); the experimental measurement yields the irreducible water saturation for a rock sample having a porosity less than a porosity threshold (step S213).
Then, the numerical correspondence between the ratio of the second formation factor (experimentally measured value) to the first formation factor (calculated value of the alrgia formula) and the irreducible water saturation is determined from the experimental data of the rock sample with the porosity smaller than the porosity threshold, and a mathematical model is established according to the numerical correspondence (step S220).
It should be noted here that, because the porosity is about 10% as a boundary in the dual logarithmic coordinate, when the porosity is greater than 10%, the relationship between the sandstone formation factor and the porosity conforms to the Archie's formula; whereas when the porosity is less than 10%, the sandstone formation factor is significantly deviated toward a decreasing direction. Therefore, in one embodiment of the present invention, 10% is used as the porosity threshold. In other embodiments of the present invention, other values with higher precision can be selected as the porosity threshold value based on actual needs.
Further, in an embodiment, in step S211, in an embodiment of the present invention, the values (a value, m value) of the lithology constants of the algic formula (formula 1) are first determined by testing data of a plurality of rock samples having a porosity greater than a porosity threshold; and then calculating the formation factor by adopting an Archie formula for the rock sample with the porosity smaller than the porosity threshold value based on the value of the lithology constant.
Specifically, in one embodiment, in determining the values of the lithology constants (a-value, m-value): the formation factor F is obtained by a rock-electricity experiment; the rock porosity phi is obtained by a physical property analysis experiment; and fitting the F and phi data to obtain a value and a value m.
Further, in an embodiment, in step S220, the numerical correspondence is obtained by fitting the second formation factor value, the first formation factor value, and the irreducible water saturation of the plurality of rock samples.
Specifically, in one embodiment, the ratio of formation factors measured experimentally to formation factors calculated by the Archie's formula is determined for rock samples having a porosity of less than 10%:
wherein FmFormation factor (second formation factor value), F, measured for petro-electric experimentsaTo adopt the Archie's formulaThe calculated formation factor (first formation factor value).
The numerical correspondence is expressed as:
c＝d×Swi+ f (type 3)
Wherein c is the ratio of the second formation factor value to the first formation factor value, SwiD and f are relational coefficients for irreducible water saturation.
Irreducible water saturation SwiCan be obtained by rock sample mercury injection experiment, nuclear magnetic resonance experiment or phase permeation experiment. C, S through multiple rock sampleswiThe data can be fitted to obtain d and f.
The calculation value of the Archie's formula of the measurement target with the porosity smaller than the porosity threshold value can be corrected based on the mathematical model according to the logging information during the well logging interpretation so as to obtain the formation factor of the measurement target.
Specifically, as shown in fig. 2, a third formation factor value (calculated value of the algi formula) of the measurement target is calculated and obtained by using the algi formula based on the logging data (step S231); irreducible water saturation of the measurement target is obtained based on the well log data (step S232). And finally, correcting the third formation factor value according to the irreducible water saturation of the measurement target and the mathematical model to obtain the formation factor value of the measurement target (step S240).
Specifically, in one embodiment, in step S231, the formation porosity φ obtained from the logging information and the a and m values obtained in step S211 are used to calculate the formation factor F according to the Archie' S equational。
Further, in one embodiment, in step S240, the formation irreducible water saturation S is obtained by using the well log datawi(step S232) and the relational expression (expression 2) obtained in step S220, the ratio c is calculated. And finally, calculating the stratum factor by the Archie formula obtained in the step S231 and calculating the compact sandstone stratum factor by the obtained ratio c:
F＝c×Fal(formula 4)
The invention aims at the problem of stratum factor acquisition in tight sandstone well logging interpretation, and establishes a new method and a new flow for acquiring stratum factors based on irreducible water saturation. Compared with the prior art, the method is simple and practical to operate, and has a good application effect in practical well logging interpretation.
Next, the effect of an embodiment of the present invention will be described based on a specific application example.
The method is utilized to obtain stratum factors for the compact sandstone stratum with the length of 8 sections of a certain oil field.
The method comprises the following steps: and carrying out a rock electricity experiment on the 14 rock samples with the porosity of more than 10 percent in the 8 sections of the oil field, measuring rock sample stratum factors, and fitting an Archie formula a value and an m value by using the rock sample stratum factors and rock sample porosity data to obtain a value 1 and a value 1.9.
Step two: and (3) calculating the formation factors by using the values a and m determined in the step one for 11 rock samples with the porosity of less than 10% in the 8 sections of the oil field and utilizing an Archie formula.
Step three: and carrying out a rock-electricity experiment on 11 rock samples with the porosity of less than 10%, measuring stratum factors of the rock samples, and calculating the ratio c of the experimental measured stratum factors of each rock sample to the stratum factors calculated by an Archie formula.
Step four: and (3) performing a nuclear magnetic resonance experiment on 11 rock samples with the porosity of less than 10%, measuring the irreducible water saturation of the rock samples, and fitting by using the measured irreducible water saturation and the ratio c obtained in the step three to obtain the d value and the f value in the formula (3), wherein the irreducible water saturation-ratio c cross-over graph is shown in fig. 3, and d is-0.0103, and f is 1.381.
Step five: and (3) logging and explaining a certain well length section of the oil field, obtaining the formation porosity phi by using logging information, obtaining the a value and the m value in the step one, and calculating the formation factors by using an Archie formula.
Step six: formation irreducible water saturation S obtained by utilizing logging informationwiThe ratio c is calculated according to equation (3).
Step seven: and (4) calculating the ratio c of the formation factor to the ratio obtained in the step six according to the Archie formula obtained in the step five, and calculating the formation factor according to the formula (4).
The results of the formation factor calculations are compared with experimentally measured formation factors, as shown in fig. 4 (the abscissa is the experimentally measured geological factor and the ordinate is the geological factor calculated according to the method of the present invention). As can be seen from FIG. 4, the data points are distributed around the 45 degree line in a centralized manner, which shows that the stratum factors obtained by the method are well matched with the stratum factors measured by the experiment, and the practicability of the method is verified.
Although the embodiments of the present invention have been described above, the above description is only for the convenience of understanding the present invention, and is not intended to limit the present invention. There are various other embodiments of the method of the present invention. Various corresponding changes or modifications may be made by those skilled in the art without departing from the spirit of the invention, and these corresponding changes or modifications are intended to fall within the scope of the appended claims.
Claims (9)
1. A method of deriving tight sandstone formation factors, comprising:
determining mathematical models among the calculated values of the Archie's formula, the measured data and the irreducible water saturation of the rock sample with the porosity less than the porosity threshold value based on the experimental data;
correcting an Archie formula calculation value of a measurement target with porosity smaller than a porosity threshold value based on the mathematical model according to logging information to obtain a formation factor of the measurement target;
wherein, the correcting the calculation value of the Archie formula of the measurement target with the porosity smaller than the porosity threshold value based on the mathematical model according to the logging information to obtain the formation factor of the measurement target comprises the following steps:
calculating and obtaining a first stratum factor value of a rock sample with porosity smaller than a porosity threshold value by utilizing an Archie formula;
obtaining a second stratum factor value of the rock sample with the porosity smaller than the porosity threshold value through experimental measurement;
and determining the numerical correspondence between the ratio of the second formation factor value to the first formation factor value and the irreducible water saturation according to experimental data of the rock sample with the porosity smaller than the porosity threshold value, and establishing the mathematical model according to the numerical correspondence.
2. The method according to claim 1, characterized in that it comprises:
calculating and obtaining a third stratum factor value of the measurement target by utilizing an Archie formula based on the logging information;
acquiring the irreducible water saturation of the measurement target based on the logging information;
and correcting the third formation factor value according to the irreducible water saturation of the measurement target and the mathematical model to obtain the formation factor value of the measurement target.
3. The method of claim 1, wherein the first formation factor value for a rock sample having a porosity less than a porosity threshold is calculated using the Archie's equation, wherein:
determining the value of the lithological constant of the Archie's formula through a plurality of rock sample experimental data with the porosity larger than the porosity threshold;
and calculating formation factors by adopting the Archie formula for rock samples with the porosity smaller than the porosity threshold value based on the value of the lithology constant.
4. The method of claim 3, wherein the values of the lithology constants of the Archie's equation are determined by experimental data on a plurality of rock samples having a porosity greater than a porosity threshold, wherein the values of the lithology constants are obtained from formation factor values and a rock porosity fit.
5. The method of claim 4, wherein the formation factor values are obtained from petroelectric experiments and the rock porosity is obtained from physical analysis experiments.
6. The method of claim 1, wherein the numerical correspondence of the ratio of the second formation factor value to the first formation factor value to irreducible water saturation is determined from experimental data for rock samples having a porosity less than a porosity threshold, wherein the numerical correspondence is obtained by fitting the second formation factor value, the first formation factor value, and irreducible water saturation for a plurality of rock samples.
7. The method of claim 6, wherein the numerical correspondence is represented by:
c＝d×Swi+f
wherein c is the ratio of the second formation factor value to the first formation factor value, SwiD and f are relational coefficients for irreducible water saturation.
8. The method of claim 1, wherein the irreducible water saturation is obtained from a rock sample mercury intrusion experiment, a nuclear magnetic resonance experiment, or a phase permeation experiment.
9. The method of any one of claims 1-8, wherein the porosity threshold is 10%.
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